lng-20240630

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2024

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 001-16383

CHENIERE ENERGY, INC.

(Exact name of registrant as specified in its charter)


Delaware			95-4352386
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

845 Texas Avenue, Suite 1250

Houston, Texas 77002

(Address of principal executive offices) (Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $ 0.003 par value	LNG	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of August 2, 2024, the issuer had 226,273,139 shares of Common Stock outstanding.

CHENIERE ENERGY, INC.

TABLE OF CONTENTS

























	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	3
	Consolidated Statements of Operations	3
	Consolidated Balance Sheets	4
	Consolidated Statements of Stockholders’ Equity (Deficit) and Redeemable Non-Controlling Interest	5
	Consolidated Statements of Cash Flows	7
	Notes to Consolidated Financial Statements	8
	Note 1—Nature of Operations and Basis of Presentation	8

	Note 2 —Trade and Other Receivables, Net of Current Expected Credit Losses	9
	Note 3 —Inventory	9
	Note 4 —Property, Plant and Equipment, Net of Accumulated Depreciation	9
	Note 5 —Derivative Instruments	10

	Note 6 —Non-Controlling Interests and Variable Interest Entities	14
	Note 7 —Accrued Liabilities	15
	Note 8 —Debt	16
	Note 9 —Leases	18
	Note 1 0 —Revenues	19
	Note 1 1 —Related Party Transactions	21
	Note 1 2 —Income Taxes	21

	Note 1 3 —Net Income per Share Attributable to Common Stockholders	22

	Note 1 4 —Share Repurchase Programs	22
	Note 1 5 —Customer Concentration	22
	Note 1 6 —Supplemental Cash Flow Information	23

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	24

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	35

Item 4.	Controls and Procedures	36

Part II. Other Information
Item 1.	Legal Proceedings	37

Item 1A.	Risk Factors	37

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	37

Item 5.	Other Information	37

Item 6.	Exhibits	38

	Signatures	39

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DEFINITIONS

As used in this quarterly report, the terms listed below have the following meanings:

Common Industry and Other Terms


ASU						Accounting Standards Update


Bcf/d						billion cubic feet per day

Bcfe						billion cubic feet equivalent
CAMT						corporate alternative minimum tax

DOE						U.S. Department of Energy
EPC						engineering, procurement and construction
ESG						environmental, social and governance
FASB						Financial Accounting Standards Board
FERC						Federal Energy Regulatory Commission
FID						final investment decision

FTA countries						countries with which the United States has a free trade agreement providing for national treatment for trade in natural gas
GAAP						generally accepted accounting principles in the United States
Henry Hub						the final settlement price (in U.S. dollars per MMBtu) for the New York Mercantile Exchange’s Henry Hub natural gas futures contract for the month in which a relevant cargo’s delivery window is scheduled to begin
IPM agreements						integrated production marketing agreements in which the gas producer sells to us gas on a global LNG or natural gas index price, less a fixed liquefaction fee, shipping and other costs

LNG						liquefied natural gas, a product of natural gas that, through a refrigeration process, has been cooled to a liquid state, which occupies a volume that is approximately 1/600th of its gaseous state
MMBtu						million British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit
mtpa						million tonnes per annum

non-FTA countries						countries with which the United States does not have a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted
SEC						U.S. Securities and Exchange Commission
SOFR						Secured Overnight Financing Rate
SPA						LNG sale and purchase agreement
TBtu						trillion British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit
Train						an industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
TUA						terminal use agreement

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Abbreviated Legal Entity Structure

The following diagram depicts our abbreviated legal entity structure as of June 30, 2024, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:

Unless the context requires otherwise, references to the “Company,” “we,” “us” and “our” refer to Cheniere Energy, Inc. and its consolidated subsidiaries, including our publicly traded subsidiary, CQP.

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PART I. FINANCIAL INFORMATION

BES

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)

(unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Revenues
LNG revenues	$	3,042	$	3,919	$	7,079	$	11,010
Regasification revenues	34		33		68		67
Other revenues	175		150		357		335

Total revenues	3,251		4,102		7,504		11,412

Operating costs and expenses (recoveries)
Cost (recovery) of sales (excluding items shown separately below)	784		912		3,020		(627)

Operating and maintenance expense	463		487		914		931
Selling, general and administrative expense	99		87		200		194
Depreciation and amortization expense	304		297		606		594



Other operating costs and expenses	13		11		22		21

Total operating costs and expenses	1,663		1,794		4,762		1,113

Income from operations	1,588		2,308		2,742		10,299

Other income (expense)
Interest expense, net of capitalized interest	(257)		(291)		(523)		(588)
Gain (loss) on modification or extinguishment of debt	(9)		(2)		(9)		18

Interest and dividend income	47		55		108		89
Other income, net	3		—		2		3
Total other expense	(216)		(238)		(422)		(478)

Income before income taxes and non-controlling interest	1,372		2,070		2,320		9,821
Less: income tax provision	210		363		319		1,679
Net income	1,162		1,707		2,001		8,142
Less: net income attributable to non-controlling interest	282		338		619		1,339
Net income attributable to Cheniere	$	880	$	1,369	$	1,382	$	6,803

Net income per share attributable to common stockholders—basic (1)	$	3.85	$	5.65	$	5.97	$	27.99
Net income per share attributable to common stockholders—diluted (1)	$	3.84	$	5.61	$	5.96	$	27.79

Weighted average number of common shares outstanding—basic	228.4		242.3		231.3		243.1
Weighted average number of common shares outstanding—diluted	228.9		243.8		231.9		244.8
___________________

(1)Earnings per share may not recalculate due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (1)

(in millions, except share data)


	June 30,		December 31,

	2024		2023
	(unaudited)
ASSETS
Current assets
Cash and cash equivalents	$	2,442	$	4,066
Restricted cash and cash equivalents	512		459
Trade and other receivables, net of current expected credit losses	719		1,106

Inventory	387		445
Current derivative assets	38		141
Margin deposits	105		18

Other current assets, net	133		96
Total current assets	4,336		6,331


Property, plant and equipment, net of accumulated depreciation	33,079		32,456
Operating lease assets	2,845		2,641

Derivative assets	1,151		863

Deferred tax assets	26		26
Other non-current assets, net	841		759
Total assets	$	42,278	$	43,076

LIABILITIES, REDEEMABLE NON-CONTROLLING INTEREST AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	124	$	181
Accrued liabilities	1,706		1,780

Current debt, net of unamortized debt issuance costs	798		300
Deferred revenue	125		179
Current operating lease liabilities	637		655
Current derivative liabilities	803		750
Other current liabilities	43		43
Total current liabilities	4,236		3,888

Long-term debt, net of unamortized discount and debt issuance costs	22,590		23,397
Operating lease liabilities	2,200		1,971
Finance lease liabilities	506		467

Derivative liabilities	2,153		2,378
Deferred tax liabilities	1,576		1,545
Other non-current liabilities	419		410
Total liabilities	33,680		34,056


Redeemable non-controlling interest	6		—

Stockholders’ equity
Preferred stock: $0.0001 par value, 5.0 million shares authorized, none issued	—		—
Common stock: $0.003 par value, 480.0 million shares authorized; 278.5 million shares and 277.9 million shares issued at June 30, 2024 and December 31, 2023, respectively	1		1



Treasury stock: 51.5 million shares and 40.9 million shares at June 30, 2024 and December 31, 2023, respectively, at cost	(5,568)		(3,864)
Additional paid-in-capital	4,406		4,377
Retained earnings	5,625		4,546
Total Cheniere stockholders’ equity	4,464		5,060
Non-controlling interest	4,128		3,960
Total stockholders’ equity	8,592		9,020
Total liabilities, redeemable non-controlling interest and stockholders’ equity	$	42,278	$	43,076

(1)Amounts presented include balances held by our consolidated variable interest entities (“VIEs”), substantially all of which are related to CQP, as further discussed in Note 6—Non-Controlling Interests and Variable Interest Entities. As of June 30, 2024, total assets and liabilities of our VIEs were $17.4 billion and $18.2 billion, respectively, including $351 million of cash and cash equivalents and $79 million of restricted cash and cash equivalents.

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (DEFICIT) AND REDEEMABLE NON-CONTROLLING INTEREST

(in millions)

(unaudited)


Three and Six Months Ended June 30, 2024
	Total Stockholders’ Equity
	Common Stock			Treasury Stock			Additional Paid-in Capital		Retained Earnings		Non-controlling Interest		Total Equity		Redeemable Non-Controlling Interest (1)
	Shares	Par Value Amount		Shares	Amount





















Balance at December 31, 2023	237.0	$	1	40.9	$	(3,864)	$	4,377	$	4,546	$	3,960	$	9,020	$	—
Vesting of share-based compensation awards	0.6	—		—	—		—		—		—		—		—
Share-based compensation	—	—		—	—		34		—		—		34		—
Issued shares withheld from employees related to share-based compensation, at cost	—	—		—	—		(40)		—		—		(40)		—
Shares repurchased, at cost	(7.5)	—		7.5	(1,203)		—		—		—		(1,203)		—

Net income	—	—		—	—		—		502		337		839		—
Contributions from redeemable non-controlling interest	—	—		—	—		—		—		—		—		4
Distributions to non-controlling interest	—	—		—	—		—		—		(253)		(253)		—
Dividends declared ($0.435 per common share)	—	—		—	—		—		(103)		—		(103)		—

Balance at March 31, 2024	230.1	1		48.4	(5,067)		4,371		4,945		4,044		8,294		4










Share-based compensation	—	—		—	—		36		—		—		36		—
Issued shares withheld from employees related to share-based compensation, at cost	—	—		—	—		(1)		—		—		(1)		—
Shares repurchased, at cost	(3.1)	—		3.1	(501)		—		—		—		(501)		—
Net income	—	—		—	—		—		880		282		1,162		—
Contributions from redeemable non-controlling interest	—	—		—	—		—		—		—		—		2
Distributions to non-controlling interest	—	—		—	—		—		—		(198)		(198)		—
Dividends declared ($0.435 per common share declared on April 26, 2024 and $0.435 per common share declared on June 17, 2024)	—	—		—	—		—		(200)		—		(200)		—

Balance at June 30, 2024	227.0	$	1	51.5	$	(5,568)	$	4,406	$	5,625	$	4,128	$	8,592	$	6

(1)Redeemable non-controlling interest represents the economic interest held by a third party in one of our consolidated VIEs that is redeemable for cash under certain circumstances, including those that are outside of our control. As such, the economic interest is not a component of permanent equity on our Consolidated Balance Sheets.

The accompanying notes are an integral part of these consolidated financial statements.

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Three and Six Months Ended June 30, 2023
	Total Stockholders’ Equity (Deficit)
	Common Stock			Treasury Stock			Additional Paid-in Capital		Retained Earnings (Accumulated Deficit)		Non-controlling Interest		Total Equity (Deficit)		Redeemable Non-Controlling Interest
	Shares	Par Value Amount		Shares	Amount
Balance at December 31, 2022	245.5	$	1	31.2	$	(2,342)	$	4,314	$	(4,942)	$	2,798	$	(171)	$	—
Vesting of share-based compensation awards	1.0	—		—	—		—		—		—		—		—
Share-based compensation	—	—		—	—		43		—		—		43		—
Issued shares withheld from employees related to share-based compensation, at cost	(0.2)	—		0.2	(26)		(29)		—		—		(55)		—
Shares repurchased, at cost	(3.1)	—		3.1	(453)		—		—		—		(453)		—

Net income	—	—		—	—		—		5,434		1,001		6,435		—
Distributions to non-controlling interest	—	—		—	—		—		—		(261)		(261)		—
Dividends declared ($0.395 per common share)	—	—		—	—		—		(98)		—		(98)		—

Balance at March 31, 2023	243.2	1		34.5	(2,821)		4,328		394		3,538		5,440		—

Share-based compensation	—	—		—	—		36		—		—		36		—
Issued shares withheld from employees related to share-based compensation, at cost	—	—		—	—		(1)		—		—		(1)		—
Shares repurchased, at cost	(2.3)	—		2.3	(341)		—		—		—		(341)		—
Net income	—	—		—	—		—		1,369		338		1,707		—
Distributions to non-controlling interest	—	—		—	—		—		—		(252)		(252)		—
Dividends declared ($0.395 per common share)	—	—		—	—		—		(97)		—		(97)		—

Balance at June 30, 2023	240.9	$	1	36.8	$	(3,162)	$	4,363	$	1,666	$	3,624	$	6,492	$	—

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)


	Six Months Ended June 30,
	2024		2023
Cash flows from operating activities
Net income	$	2,001	$	8,142
Adjustments to reconcile net income to net cash provided by operating activities:
Unrealized foreign currency exchange loss (gain), net	3		(2)
Depreciation and amortization expense	606		594
Share-based compensation expense	92		85

Amortization of discount and debt issuance costs	19		23
Reduction of right-of-use assets	330		315
Loss (gain) on modification or extinguishment of debt	9		(18)
Total gains on derivative instruments, net	(393)		(5,411)
Net cash provided by (used for) settlement of derivative instruments	36		(102)


Deferred taxes	41		1,581

Other, net	8		6
Changes in operating assets and liabilities:
Trade and other receivables	387		1,249

Inventory	56		418
Margin deposits	(88)		98


Accounts payable and accrued liabilities	(324)		(1,551)

Total deferred revenue	(41)		(78)
Total operating lease liabilities	(324)		(305)

Other, net	(56)		(44)
Net cash provided by operating activities	2,362		5,000

Cash flows from investing activities
Property, plant and equipment, net	(1,153)		(1,044)

Investment in equity method investments	(12)		(18)
Other	(20)		(6)
Net cash used in investing activities	(1,185)		(1,068)

Cash flows from financing activities
Proceeds from issuances of debt	2,725		1,397
Redemptions, repayments and repurchases of debt	(3,021)		(1,098)



Distributions to non-controlling interest	(451)		(513)

Payments related to tax withholdings for share-based compensation	(41)		(56)
Repurchase of common stock	(1,699)		(774)
Dividends to stockholders	(202)		(195)

Other, net	(57)		(14)
Net cash used in financing activities	(2,746)		(1,253)

Effect of exchange rate changes on cash, cash equivalents and restricted cash and cash equivalents	(2)		3

Net increase (decrease) in cash, cash equivalents and restricted cash and cash equivalents	(1,571)		2,682
Cash, cash equivalents and restricted cash and cash equivalents—beginning of period	4,525		2,487
Cash, cash equivalents and restricted cash and cash equivalents—end of period	$	2,954	$	5,169

The accompanying notes are an integral part of these consolidated financial statements.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We operate two natural gas liquefaction and export facilities located in Cameron Parish, Louisiana at Sabine Pass and near Corpus Christi, Texas (respectively, the “Sabine Pass LNG Terminal” and “Corpus Christi LNG Terminal”).

CQP owns the Sabine Pass LNG Terminal, which has natural gas liquefaction facilities consisting of six operational Trains, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG Terminal also has operational regasification facilities that include five LNG storage tanks, vaporizers and three marine berths. We also own and operate a 94-mile natural gas supply pipeline that interconnects the Sabine Pass LNG Terminal with several large interstate and intrastate pipelines (the “Creole Trail Pipeline”). As of June 30, 2024, we owned 100% of the general partner interest, a 48.6% limited partner interest and 100% of the incentive distribution rights of CQP.

The Corpus Christi LNG Terminal currently has three operational Trains for a total production capacity of approximately 15 mtpa of LNG, three LNG storage tanks and two marine berths. Additionally, we are constructing an expansion of the Corpus Christi LNG Terminal (the “Corpus Christi Stage 3 Project”) consisting of seven midscale Trains with an expected total production capacity of over 10 mtpa of LNG. We also own a 21.5-mile natural gas supply pipeline that interconnects the Corpus Christi LNG Terminal with several large interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the existing assets at the Corpus Christi LNG Terminal and the Corpus Christi Stage 3 Project, the “CCL Project”).

We are pursuing expansion projects to provide additional liquefaction capacity at the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”), and we have commenced commercialization to support the additional liquefaction capacity associated with these potential expansion projects. The development of these sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a positive FID.

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X and reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair statement of the financial results for the interim periods presented. Accordingly, these Consolidated Financial Statements do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

Results of operations for the three and six months ended June 30, 2024 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2024.

Recent Accounting Standards

ASU 2023-07

In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280). This guidance requires a public entity, including entities with a single reportable segment, to disclose significant segment expenses and other segment items on an annual and interim basis and provide in interim periods all disclosures about a reportable segment’s profit or loss and assets that are currently required annually. We plan to adopt this guidance and conform with the applicable disclosures retrospectively when it becomes mandatorily effective for our annual report for the year ending December 31, 2024.

ASU 2023-09

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740). This guidance further enhances income tax disclosures, primarily through standardization and disaggregation of rate reconciliation categories and income taxes paid by jurisdiction. We plan to adopt this guidance and conform with the disclosure requirements when it becomes mandatorily effective for our annual report for the year ending December 31, 2025.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 2—TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES

Trade and other receivables, net of current expected credit losses, consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
Trade receivables
SPL and CCL	$	431	$	525

Cheniere Marketing	212		451
Other	4		4
Other receivables	72		126
Total trade and other receivables, net of current expected credit losses	$	719	$	1,106

NOTE 3—INVENTORY

Inventory consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
Materials	$	213	$	207
LNG	75		88
LNG in-transit	73		112
Natural gas	24		35
Other	2		3
Total inventory	$	387	$	445

NOTE 4—PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION

Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
Terminal and related assets
Terminal and interconnecting pipeline facilities	$	34,154	$	34,069
Land	464		463
Construction-in-process	4,555		3,480
Accumulated depreciation	(6,668)		(6,099)
Total terminal and related assets, net of accumulated depreciation	32,505		31,913
Fixed assets and other
Computer and office equipment	39		37
Furniture and fixtures	31		31
Computer software	128		125
Leasehold improvements	44		43

Other	22		21
Accumulated depreciation	(191)		(183)
Total fixed assets and other, net of accumulated depreciation	73		74
Assets under finance leases
Marine assets	583		532
Accumulated depreciation	(82)		(63)
Total assets under finance leases, net of accumulated depreciation	501		469
Property, plant and equipment, net of accumulated depreciation	$	33,079	$	32,456

Depreciation expense was $303 million and $295 million during the three months ended June 30, 2024 and 2023, respectively, and $603 million and $591 million during the six months ended June 30, 2024 and 2023, respectively.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 5—DERIVATIVE INSTRUMENTS

We have entered into the following derivative instruments:

•commodity derivatives consisting of the following (collectively, “Commodity Derivatives”):

◦natural gas and power supply contracts, including those under our IPM agreements, for the development, commissioning and operation of the Liquefaction Projects and expansion projects, as well as the associated economic hedges (collectively, the “Liquefaction Supply Derivatives”); and,

◦LNG derivatives in which we have contractual net settlement and economic hedges on the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”); and

•foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with cash flows denominated in currencies other than U.S. dollar (“FX Derivatives”), associated with both LNG Trading Derivatives and operations in countries outside of the United States.

We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow, fair value or net investment hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations to the extent not utilized for the commissioning process, in which case such changes are capitalized.

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis, distinguished by the fair value hierarchy levels prescribed by GAAP (in millions):


	Fair Value Measurements as of
	June 30, 2024								December 31, 2023
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total


Liquefaction Supply Derivatives asset (liability)	$	(24)	$	—	$	(1,729)	$	(1,753)	$	25	$	36	$	(2,178)	$	(2,117)
LNG Trading Derivatives asset (liability)	(11)		(6)		—		(17)		30		(20)		—		10
FX Derivatives asset (liability)	—		3		—		3		—		(17)		—		(17)

We value the Liquefaction Supply Derivatives and LNG Trading Derivatives using a market or option-based approach incorporating present value techniques, as needed, which incorporates observable commodity price curves, when available, and other relevant data. We value our FX Derivatives with a market approach using observable FX rates and other relevant data.

We include a significant portion of the Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which incorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that market participants may use in valuing the asset or liability. To the extent valued using an option pricing model, we consider the future prices of energy units for unobservable periods to be a significant unobservable input to estimated net fair value. In estimating the future prices of energy units, we make judgments about market risk related to liquidity of commodity indices and volatility utilizing available market data. Changes in facts and circumstances or additional information may result in revised estimates and judgments, and actual results may differ from these estimates and judgments. We derive our volatility assumptions based on observed historical settled global LNG market pricing or accepted proxies for global LNG market pricing as well as settled domestic natural gas pricing. Such volatility assumptions also contemplate, as of the balance sheet date, observable forward curve data of such indices, as well as evolving available industry data and independent studies.

In developing our volatility assumptions, we acknowledge that the global LNG industry is inherently influenced by events such as unplanned supply constraints, geopolitical incidents, unusual climate events including drought and uncommonly mild, by historical standards, winters and summers, and real or threatened disruptive operational impacts to global energy

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infrastructure. Our current estimate of volatility includes the impact of otherwise rare events unless we believe market participants would exclude such events on account of their assertion that those events were specific to our company and deemed within our control. As applicable to our natural gas supply contracts, our fair value estimates incorporate market participant-based assumptions pertaining to certain contractual uncertainties, including those related to the availability of market information for delivery points, as well as the timing of satisfaction of certain events or development of infrastructure to support natural gas gathering and transport. We may recognize changes in fair value through earnings that could significantly impact our results of operations if and when such uncertainties are resolved.

The Level 3 fair value measurements of our natural gas positions within the Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of June 30, 2024:

Net Fair Value Liability

(in millions)

Valuation Approach

Significant Unobservable Input

Range of Significant Unobservable Inputs / Weighted Average (1)

Liquefaction Supply Derivatives

$(1,729)

Market approach incorporating present value techniques

Henry Hub basis spread

$(2.063) - $0.445 / $(0.107)

Option pricing model

International LNG pricing spread, relative to Henry Hub (2)

23% - 394% / 175%

(1)Unobservable inputs were weighted by the relative fair value of the instruments.

(2)Spread contemplates U.S. dollar-denominated pricing.

Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of the Liquefaction Supply Derivatives.

The following table shows the changes in the fair value of the Level 3 Liquefaction Supply Derivatives (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Balance, beginning of period	$	(2,457)	$	(5,426)	$	(2,178)	$	(9,924)
Realized and change in fair value gains included in net income (1):
Included in cost of sales, existing deals (2)	617		635		164		4,518
Included in cost of sales, new deals (3)	7		3		5		9
Purchases and settlements:
Purchases (4)	—		—		—		—
Settlements (5)	104		175		280		780


Transfers out of level 3 (6)	—		2		—		6
Balance, end of period	$	(1,729)	$	(4,611)	$	(1,729)	$	(4,611)
Favorable changes in fair value relating to instruments still held at the end of the period	$	624	$	638	$	169	$	4,527

(1)Does not include the realized value associated with derivative instruments that settle through physical delivery, as settlement is equal to the contractually fixed price from trade date multiplied by contractual volume. See settlements line item in this table.

(2)Impact to earnings on deals that existed at the beginning of the period and continue to exist at the end of the period.

(3)Impact to earnings on deals that were entered into during the reporting period and continue to exist at the end of the period.

(4)Includes any day one gain (loss) recognized during the reporting period on deals that were entered into during the reporting period which continue to exist at the end of the period.

(5)Roll-off in the current period of amounts recognized in our Consolidated Balance Sheets at the end of the previous period due to settlement of the underlying instruments in the current period.

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(6)Transferred out of Level 3 as a result of observable market for the underlying natural gas purchase agreements.

Commodity Derivatives

We hold Liquefaction Supply Derivatives which are primarily indexed to the natural gas market and international LNG indices. As of June 30, 2024, the remaining fixed terms of the Liquefaction Supply Derivatives ranged up to approximately 15 years, some of which commence or accelerate upon the satisfaction of certain events or development of infrastructure to support natural gas gathering and transport.

Cheniere Marketing has historically entered into, and may from time to time enter into, LNG transactions that provide for contractual net settlement. Such transactions are accounted for as LNG Trading Derivatives along with financial commodity contracts in the form of swaps or futures. The terms of LNG Trading Derivatives range up to approximately one year.

The following table shows the notional amounts of our Commodity Derivatives:

June 30, 2024

December 31, 2023

Liquefaction Supply Derivatives (1)

LNG Trading Derivatives

Liquefaction Supply Derivatives (1)

LNG Trading Derivatives

Notional amount, net (in TBtu)

13,520

—

14,019

(1)Inclusive of amounts under contracts with unsatisfied contractual conditions and exclusive of extension options that were uncertain to be taken as of both June 30, 2024 and December 31, 2023.

The following table shows the effect and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations (in millions):


		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location (1)	Three Months Ended June 30,				Six Months Ended June 30,
		2024		2023		2024		2023

LNG Trading Derivatives	LNG revenues	$	1	$	(46)	$	17	$	15
LNG Trading Derivatives	Recovery (cost) of sales	(1)		(3)		(20)		(87)
Liquefaction Supply Derivatives (2)	LNG revenues	2		(1)		2		(6)
Liquefaction Supply Derivatives (2)	Recovery (cost) of sales	647		826		379		5,497

(1)Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

(2)Does not include the realized value associated with the Liquefaction Supply Derivatives that settle through physical delivery.

FX Derivatives

Cheniere Marketing holds FX Derivatives to protect against the volatility in future cash flows attributable to changes in international currency exchange rates. The FX Derivatives are executed primarily to economically hedge the foreign currency exposure arising from cash flows expended for both physical and financial LNG transactions that are denominated in a currency other than the U.S. dollar. The terms of FX Derivatives range up to approximately one year.

The total notional amount of our FX Derivatives was $214 million and $789 million as of June 30, 2024 and December 31, 2023, respectively.

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The following table shows the effect and location of our FX Derivatives recorded on our Consolidated Statements of Operations (in millions):


		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended June 30,				Six Months Ended June 30,
		2024		2023		2024		2023
FX Derivatives	LNG revenues	$	2	$	(6)	$	15	$	(8)

Fair Value and Location of Derivative Assets and Liabilities on the Consolidated Balance Sheets

All existing counterparty derivative contracts provide for the unconditional right of set-off in the event of default. We have elected to report derivative assets and liabilities arising from those derivative contracts with the same counterparty and the unconditional contractual right of set-off on a net basis. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments, in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements depending on the position of the derivative. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

The following table shows the fair value and location of our derivative instruments on our Consolidated Balance Sheets (in millions):


	June 30, 2024
	Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	33	$	2	$	3	$	38
Derivative assets	1,151		—		—		1,151
Total derivative assets	1,184		2		3		1,189

Current derivative liabilities	(784)		(19)		—		(803)
Derivative liabilities	(2,153)		—		—		(2,153)
Total derivative liabilities	(2,937)		(19)		—		(2,956)

Derivative asset (liability), net	$	(1,753)	$	(17)	$	3	$	(1,767)

	December 31, 2023
	Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	49	$	92	$	—	$	141
Derivative assets	863		—		—		863
Total derivative assets	912		92		—		1,004

Current derivative liabilities	(651)		(82)		(17)		(750)
Derivative liabilities	(2,378)		—		—		(2,378)
Total derivative liabilities	(3,029)		(82)		(17)		(3,128)

Derivative asset (liability), net	$	(2,117)	$	10	$	(17)	$	(2,124)

(1)Does not include collateral posted with counterparties by us of $49 million and $3 million as of June 30, 2024 and December 31, 2023, respectively, which is included in margin deposits on our Consolidated Balance Sheets, and collateral posted by counterparties to us of zero and $4 million as of June 30, 2024 and December 31, 2023, respectively, which is included in other current liabilities on our Consolidated Balance Sheets.

(2)Does not include collateral posted with counterparties by us of $56 million and $15 million, as of June 30, 2024 and December 31, 2023, respectively, which is included in margin deposits on our Consolidated Balance Sheets, and

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collateral posted by counterparties to us of zero and $3 million as of June 30, 2024 and December 31, 2023, respectively, which is included in other current liabilities on our Consolidated Balance Sheets.

Consolidated Balance Sheets Presentation

The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions) for our derivative instruments that are presented on a net basis on our Consolidated Balance Sheets:


	Liquefaction Supply Derivatives		LNG Trading Derivatives		FX Derivatives

As of June 30, 2024
Gross assets	$	1,536	$	20	$	4
Offsetting amounts	(352)		(18)		(1)
Net assets (1)	$	1,184	$	2	$	3

Gross liabilities	$	(3,064)	$	(33)	$	—
Offsetting amounts	127		14		—
Net liabilities (2)	$	(2,937)	$	(19)	$	—

As of December 31, 2023
Gross assets	$	1,272	$	94	$	—
Offsetting amounts	(360)		(2)		—
Net assets (1)	$	912	$	92	$	—

Gross liabilities	$	(3,095)	$	(110)	$	(17)
Offsetting amounts	66		28		—
Net liabilities (2)	$	(3,029)	$	(82)	$	(17)

(1)Includes current and non-current derivative assets of $38 million and $1,151 million, respectively, as of June 30, 2024 and $141 million and $863 million, respectively, as of December 31, 2023.

(2)Includes current and non-current derivative liabilities of $803 million and $2,153 million, respectively, as of June 30, 2024 and $750 million and $2,378 million, respectively, as of December 31, 2023.

NOTE 6—NON-CONTROLLING INTERESTS AND VARIABLE INTEREST ENTITIES

When we consolidate our VIEs, we include 100% of the assets, liabilities, revenues and expenses of the VIE in our Consolidated Financial Statements; however, when our ownership is less than 100%, we record a non-controlling interest as a component of equity or redeemable non-controlling interest on our Consolidated Balance Sheets, which represents the third party ownership in the net assets of the respective consolidated subsidiary. Additionally, the portion of the net income or loss attributable to the non-controlling interests is reported as net income attributable to non-controlling interest on our Consolidated Statements of Operations.

Substantially all of our consolidated VIEs’ assets and liabilities relate to CQP. We own a 48.6% limited partner interest in CQP, and we also own all of the 2% general partner interest and 100% of the incentive distribution rights in CQP. The remaining 49.4% non-controlling limited partner interest in CQP is held by affiliates of Blackstone Inc. and Brookfield Asset Management, Inc. (“Brookfield”) as well as the public.

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The following table presents the summarized consolidated assets and liabilities (in millions) of our consolidated VIEs, which are included in our Consolidated Balance Sheets. The assets in the table below may only be used to settle obligations of the respective VIEs. In addition, there is no recourse to us for the consolidated VIEs’ liabilities. The assets and liabilities in the table below include third party assets and liabilities of the VIEs only and exclude intercompany balances between the respective VIEs and Cheniere that eliminate in our Consolidated Financial Statements.


	June 30,		December 31,

	2024		2023
ASSETS
Current assets
Cash and cash equivalents	$	351	$	575
Restricted cash and cash equivalents	79		56
Trade and other receivables, net of current expected credit losses	291		373

Other current assets, net	260		215
Total current assets	981		1,219


Property, plant and equipment, net of accumulated depreciation	16,108		16,212
Other non-current assets, net	298		309

Total assets	$	17,387	$	17,740

LIABILITIES
Current liabilities

Accrued liabilities	$	684	$	811
Current debt, net of discount and debt issuance costs	798		300
Current derivative liabilities	235		196
Other current liabilities	138		201

Total current liabilities	1,855		1,508

Long-term debt, net of unamortized discount and debt issuance costs	14,803		15,606

Derivative liabilities	1,319		1,531
Other non-current liabilities	249		160
Total liabilities	$	18,226	$	18,805

NOTE 7—ACCRUED LIABILITIES

Accrued liabilities consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
Natural gas purchases	$	552	$	729

Interest costs and related debt fees	362		399
Terminal and related asset costs	271		235
Tax-related liabilities	190		68
Compensation and benefits	152		266
Accrued dividends	101		3
LNG purchases	48		23
Other accrued liabilities	30		57
Total accrued liabilities	$	1,706	$	1,780

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NOTE 8—DEBT

Debt consisted of the following (in millions):


	June 30,		December 31,

	2024		2023
SPL:
Senior Secured Notes:


5.750% due 2024	$	—	$	300
5.625% due 2025	800		2,000
5.875% due 2026	1,500		1,500
5.00% due 2027	1,500		1,500
4.200% due 2028	1,350		1,350
4.500% due 2030	2,000		2,000
4.746% weighted average rate due 2037	1,782		1,782
Total SPL Senior Secured Notes	8,932		10,432
Revolving credit and guaranty agreement (the “SPL Revolving Credit Facility”)	—		—
Total debt - SPL	8,932		10,432

CQP:
Senior Notes:


4.500% due 2029	1,500		1,500
4.000% due 2031	1,500		1,500
3.25% due 2032	1,200		1,200
5.950% due 2033	1,400		1,400
5.750% due 2034	1,200		—
Total CQP Senior Notes	6,800		5,600
Revolving credit and guaranty agreement (the “CQP Revolving Credit Facility”)	—		—
Total debt - CQP	6,800		5,600

CCH:
Senior Secured Notes:

5.875% due 2025	—		1,491
5.125% due 2027	1,201		1,201
3.700% due 2029	1,125		1,125
3.788% weighted average rate due 2039	2,539		2,539
Total CCH Senior Secured Notes	4,865		6,356
Term loan facility agreement (the “CCH Credit Facility”)	—		—
Working capital facility agreement (the “CCH Working Capital Facility”)	—		—
Total debt - CCH	4,865		6,356

Cheniere:
4.625% Senior Notes due 2028	1,500		1,500
5.650% Senior Notes due 2034	1,500		—
Total Cheniere Senior Notes	3,000		1,500
Revolving credit agreement (the “Cheniere Revolving Credit Facility”)	—		—

Total debt - Cheniere	3,000		1,500


Total debt	23,597		23,888

Current debt, net of unamortized debt issuance costs	(798)		(300)

Unamortized discount and debt issuance costs	(209)		(191)
Total long-term debt, net of unamortized discount and debt issuance costs	$	22,590	$	23,397

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Credit Facilities

Below is a summary of our committed credit facilities outstanding as of June 30, 2024 (in millions):


	SPL Revolving Credit Facility		CQP Revolving Credit Facility		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility
Total facility size	$	1,000	$	1,000	$	3,260	$	1,500	$	1,250

Less:
Outstanding balance	—		—		—		—		—

Letters of credit issued	238		—		—		110		—
Available commitment	$	762	$	1,000	$	3,260	$	1,390	$	1,250

Priority ranking	Senior secured		Senior unsecured		Senior secured		Senior secured		Unsecured
Interest rate on available balance (1)	SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.75% or base rate plus 0.0% - 0.75%		SOFR plus credit spread adjustment of 0.1%, plus margin of 1.125% - 2.0% or base rate plus 0.125% - 1.0%		SOFR plus credit spread adjustment of 0.1%, plus margin of 1.5% or base rate plus 0.5%		SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.5% or base rate plus 0.0% - 0.5%		SOFR plus credit spread adjustment of 0.1%, plus margin of 1.075% - 2.20% or base rate plus 0.075% - 1.2%

Commitment fees on undrawn balance (1)	0.075% - 0.30%		0.10% - 0.30%		0.525%		0.10% - 0.20%		0.115% - 0.365%
Maturity date	June 23, 2028		June 23, 2028		(2)		June 15, 2027		October 28, 2026

(1)The margin on the interest rate and the commitment fees is subject to change based on the applicable entity’s credit rating.

(2)The CCH Credit Facility matures the earlier of June 15, 2029 or two years after the substantial completion of the last Train of the Corpus Christi Stage 3 Project.

In addition, as of June 30, 2024, Cheniere Marketing had trade finance facilities with no outstanding borrowings and $65 million in standby letters of credit and bank guarantees issued.

Restrictive Debt Covenants

The indentures governing our senior notes and other agreements underlying our debt contain customary terms and events of default and certain covenants that, among other things, may limit us, our subsidiaries’ and its restricted subsidiaries’ ability to make certain investments or pay dividends or distributions. SPL and CCH are restricted from making distributions under agreements governing their respective indebtedness generally until, among other requirements, appropriate reserves have been established for debt service using cash or letters of credit and a historical debt service coverage ratio and projected debt service coverage ratio of at least 1.25:1.00 is satisfied.

As of June 30, 2024, each of our issuers was in compliance with all covenants related to their respective debt agreements.

Interest Expense

Total interest expense, net of capitalized interest, consisted of the following (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Total interest cost	$	309	$	319	$	620	$	640
Capitalized interest	(52)		(28)		(97)		(52)
Total interest expense, net of capitalized interest	$	257	$	291	$	523	$	588

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Fair Value Disclosures

The following table shows the carrying amount and estimated fair value of our senior notes (in millions):


	June 30, 2024				December 31, 2023
	Carrying Amount		Estimated Fair Value (1)		Carrying Amount		Estimated Fair Value (1)
Senior notes	$	23,597	$	22,569	$	23,888	$	23,062

(1)As of both June 30, 2024 and December 31, 2023, $3.0 billion of the fair value of our senior notes was classified as Level 3 since these senior notes were valued by applying an unobservable illiquidity adjustment to the price derived from trades or indicative bids of instruments with similar terms, maturities and credit standing. The remainder of the fair value of our senior notes are classified as Level 2, based on prices derived from trades or indicative bids of the instruments.

The estimated fair value of our credit facilities approximates the principal amount outstanding because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

NOTE 9—LEASES

We are the lessee of LNG vessels leased under time charters (“vessel charters”) as well as tug vessels, office space and facilities, land sites and other equipment. All of our leases where we are the lessee are classified as operating leases except for certain of our vessel charters, tug vessels and other equipment, which are classified as finance leases.

Future annual minimum lease payments for operating and finance leases as of June 30, 2024 are as follows (in millions):


Years Ending December 31,	Operating Leases		Finance Leases
2024	$	409	$	35
2025	671		72
2026	538		75
2027	441		77
2028	287		73
Thereafter	932		355
Total lease payments (1)	3,278		687
Less: Interest	(441)		(140)
Present value of lease liabilities	$	2,837	$	547

(1)Does not include approximately $3.3 billion of legally binding minimum payments for leases executed as of June 30, 2024 that will commence in future periods, consisting primarily of vessel charters, with fixed minimum lease terms of up to 15 years.

The following table shows the weighted-average remaining lease term and the weighted-average discount rate for our operating leases and finance leases:


	June 30, 2024		December 31, 2023
	Operating Leases	Finance Leases	Operating Leases	Finance Leases
Weighted-average remaining lease term (in years)	6.8	9.3	6.3	9.7
Weighted-average discount rate (1)	5.0%	7.5%	4.7%	7.7%

(1)The weighted average discount rate is impacted by certain finance leases that commenced prior to the adoption of the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

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The following table includes other quantitative information for our operating and finance leases (in millions):


	Six Months Ended June 30,
	2024		2023




Right-of-use assets obtained in exchange for operating lease liabilities (1)	$	568	$	177
Right-of-use assets obtained in exchange for finance lease liabilities (2)	74		5

(1)Includes $15 million reclassified from finance leases to operating leases during the six months ended June 30, 2024, as a result of modifications of the underlying tug vessel leases.

(2)Includes $33 million reclassified from operating leases to finance leases during the six months ended June 30, 2024, as a result of modifications of the underlying tug vessel leases.

LNG Vessel Subleases

We sublease certain LNG vessels under charter to third parties while retaining our existing obligation to the original lessor. All of our sublease arrangements have been assessed as operating leases. The following table shows the sublease income recognized in other revenues on our Consolidated Statements of Operations (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Fixed income	$	67	$	97	$	165	$	231
Variable income	12		13		18		36
Total sublease income	$	79	$	110	$	183	$	267

Future annual minimum sublease payments to be received from LNG vessel subleases as of June 30, 2024 are as follows (in millions):


Years Ending December 31,	Sublease Payments
2024	$	78
2025	13




Total sublease payments	$	91

NOTE 10—REVENUES

The following table represents a disaggregation of revenue earned (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Revenues from contracts with customers
LNG revenues (excluding net derivative gain (loss) below)	$	3,037	$	3,972	$	7,045	$	11,009
Regasification revenues	34		33		68		67
Other revenues (1)	76		42		151		70

Total revenues from contracts with customers	3,147		4,047		7,264		11,146
Net derivative gain (loss) (see Note 5)	5		(53)		34		1
Sublease income (see Note 9)	79		110		183		267
Other revenues	20		(2)		23		(2)
Total revenues	$	3,251	$	4,102	$	7,504	$	11,412

(1)Includes revenues from LNG vessel subcharters that do not qualify as leases for accounting purposes.

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(unaudited)

Contract Assets and Liabilities

The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets, net and other non-current assets, net on our Consolidated Balance Sheets (in millions):


	June 30,		December 31,

	2024		2023
Contract assets, net of current expected credit losses	$	298	$	250

The following table reflects the changes in our contract liabilities, which are included in deferred revenue and other non-current liabilities on our Consolidated Balance Sheets (in millions):



	Six Months Ended June 30, 2024
Deferred revenue, beginning of period	$	294
Cash received but not yet recognized in revenue	128
Revenue recognized from prior period deferral	(154)
Deferred revenue, end of period	$	268

Transaction Price Allocated to Future Performance Obligations

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied:


	June 30, 2024			December 31, 2023
	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues (2)	$	107.8	9	$	111.0	9
Regasification revenues	0.6		3	0.7		3
Total revenues	$	108.4		$	111.7

(1)The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

(2)We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching FID on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are included in the transaction price above when the conditions are considered probable of being met and consideration is not otherwise constrained from ultimate pricing and receipt.

The following potential future sources of revenue are omitted from the table above under exemptions we have elected: (1) all performance obligations that are part of a contract that has an original expected duration of one year or less and (2) substantially all variable consideration under our SPAs and TUAs as well as variable consideration that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation when that performance obligation qualifies as a series. The amount of revenue from variable fees that is not included in the transaction price will vary based on the future prices of the underlying variable index, primarily Henry Hub, throughout the contract terms, to the extent customers elect to take delivery of their LNG, and adjustments to the consumer price index. Certain of our contracts contain additional variable consideration based on the outcome of contingent events and the movement of various indexes. We have not included such variable consideration in the transaction price to the extent the consideration is considered constrained due to the uncertainty of ultimate pricing and receipt. Additionally, we have excluded variable consideration related to volumes that are contractually subject to additional liquefaction capacity beyond what is currently in construction or operation.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table summarizes the amount of variable consideration earned under contracts with customers included in the table above:


	Three Months Ended June 30,				Six Months Ended June 30,

	2024		2023		2024		2023
LNG revenues	50	%	64	%	56	%	73	%
Regasification revenues	8	%	7	%	8	%	7	%

NOTE 11—RELATED PARTY TRANSACTIONS

Below is a summary of our related party transactions, all in the ordinary course of business, as reported on our Consolidated Statements of Operations (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023



Other revenues
Operating Agreement and Construction Management Agreement with Midship Pipeline Company, LLC (“Midship Pipeline”) (1)	$	2	$	2	$	4	$	5







Operating and maintenance expense
Natural Gas Transportation and Storage Agreements with Midship Pipeline (2)	3		2		5		4
Natural Gas Transportation and Storage Agreements with a related party through Brookfield (2)	16		14		29		30

(1)Midship Pipeline is a subsidiary of Midship Holdings, LLC, which we recognize as an equity method investment.

(2)This related party is partially owned by Brookfield, who indirectly owns a portion of CQP’s limited partner interests.

Below is a summary of our related party balances, all in the ordinary course of business, as reported on our Consolidated Balance Sheets (in millions):


	June 30,		December 31,

	2024		2023
Trade and other receivables, net of current expected credit losses	$	2	$	3

Accrued liabilities	5		6

NOTE 12—INCOME TAXES

We recorded an income tax provision of $210 million and $319 million during the three and six months ended June 30, 2024, respectively, and an income tax provision of $363 million and $1.7 billion for the same periods of 2023, respectively, which was calculated using the annual effective tax rate method.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 13—NET INCOME PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

The following table reconciles basic and diluted weighted average common shares outstanding and common stock dividends declared (in millions, except per share data):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Net income attributable to Cheniere	$	880	$	1,369	$	1,382	$	6,803



Weighted average common shares outstanding:
Basic	228.4		242.3		231.3		243.1
Dilutive unvested stock	0.5		1.5		0.6		1.7

Diluted	228.9		243.8		231.9		244.8

Net income per share attributable to common stockholders—basic (1)	$	3.85	$	5.65	$	5.97	$	27.99
Net income per share attributable to common stockholders—diluted (1)	$	3.84	$	5.61	$	5.96	$	27.79

(1)Earnings per share in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

On June 17, 2024, we declared a quarterly dividend of $0.435 per share of common stock that is payable on August 16, 2024 to stockholders of record as of the close of business on August 9, 2024.

NOTE 14—SHARE REPURCHASE PROGRAMS

The following table presents information with respect to common stock repurchased under our share repurchase program (in millions, except per share data):


	Three Months Ended June 30,				Six Months Ended June 30,
	2024		2023		2024		2023
Total shares repurchased	3.14		2.30		10.66		5.36
Weighted average price paid per share	$	158.00	$	146.56	$	158.31	$	146.90
Total cost of repurchases (1)	$	496	$	337	$	1,688	$	788

(1)Amount excludes associated commission fees and excise taxes incurred, which are excluded costs under the repurchase program.

As of June 30, 2024, we had approximately $4.5 billion remaining under our share repurchase program, subsequent to authorization by our Board of Directors to increase our previous authorization by $4.0 billion on June 14, 2024. Our share repurchase program authorization is effective through December 31, 2027.

NOTE 15—CUSTOMER CONCENTRATION

The concentration of our customer credit risk in excess of 10% of total revenues and/or trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses was as follows:

Percentage of Total Revenues from External Customers

Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers

Three Months Ended June 30,

Six Months Ended June 30,

June 30,

December 31,

2024

2023

2024

2023

2024

2023

Customer A

19%

13%

Customer B

11%

* Less than 10%

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 16—SUPPLEMENTAL CASH FLOW INFORMATION

The following table provides supplemental disclosure of substantive cash flow information (in millions):


	Six Months Ended June 30,
	2024		2023
Cash paid during the period for interest on debt, net of amounts capitalized	$	499	$	685
Cash paid for income taxes, net	21		54
Non-cash investing activity (1):
Unpaid purchases of property, plant and equipment, net	229		53





Non-cash financing activity (1):

Unpaid excise taxes on repurchase of common stock	15		6
Unpaid repurchase on common stock	—		13
Unpaid dividends on common stock	99		2

(1)Reflects unpaid portion, as of the end of each period, of assets and liabilities recognized during the respective periods.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Information Regarding Forward-Looking Statements

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical or present facts or conditions, included herein or incorporated herein by reference are “forward-looking statements.” Included among “forward-looking statements” are, among other things:

•statements that we expect to commence or complete construction of our proposed LNG terminals, liquefaction facilities, pipeline facilities or other projects, or any expansions or portions thereof, by certain dates, or at all;

•statements regarding future levels of domestic and international natural gas production, supply or consumption or future levels of LNG imports into or exports from North America and other countries worldwide or purchases of natural gas, regardless of the source of such information, or the transportation or other infrastructure or demand for and prices related to natural gas, LNG or other hydrocarbon products;

•statements regarding any financing transactions or arrangements, or our ability to enter into such transactions;

•statements relating to Cheniere’s capital deployment, including intent, ability, extent and timing of capital expenditures, debt repayment, dividends, share repurchases and execution on the capital allocation plan;

•statements regarding our future sources of liquidity and cash requirements;

•statements relating to the construction of our Trains and pipelines, including statements concerning the engagement of any EPC contractor or other contractor and the anticipated terms and provisions of any agreement with any EPC or other contractor, and anticipated costs related thereto;

•statements regarding any SPA or other agreement to be entered into or performed substantially in the future, including any revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total LNG regasification, natural gas liquefaction or storage capacities that are, or may become, subject to contracts;

•statements regarding counterparties to our commercial contracts, construction contracts and other contracts;

•statements regarding our planned development and construction of additional Trains or pipelines, including the financing of such Trains or pipelines;

•statements that our Trains, when completed, will have certain characteristics, including amounts of liquefaction capacities;

•statements regarding our business strategy, our strengths, our business and operation plans or any other plans, forecasts, projections, or objectives, including anticipated revenues, capital expenditures, maintenance and operating costs and cash flows, any or all of which are subject to change;

•statements relating to our goals, commitments and strategies in relation to environmental matters;

•statements regarding legislative, governmental, regulatory, administrative or other public body actions, approvals, requirements, permits, applications, filings, investigations, proceedings or decisions;

•statements regarding our anticipated LNG and natural gas marketing activities; and

•any other statements that relate to non-historical or future information.

All of these types of statements, other than statements of historical or present facts or conditions, are forward-looking statements. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “achieve,” “anticipate,” “believe,” “contemplate,” “continue,” “estimate,” “expect,” “intend,” “plan,” “potential,” “predict,” “project,” “pursue,” “target,” the negative of such terms or other comparable terminology. The forward-looking statements contained in this quarterly report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe that such estimates are reasonable, they are inherently uncertain and involve a number of risks and uncertainties beyond our control. In addition, assumptions may prove to be inaccurate. We caution that

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the forward-looking statements contained in this quarterly report are not guarantees of future performance and that such statements may not be realized or the forward-looking statements or events may not occur. Actual results may differ materially from those anticipated or implied in forward-looking statements as a result of a variety of factors described in this quarterly report and in the other reports and other information that we file with the SEC, including those discussed under “Risk Factors” in our annual report on Form 10-K for the fiscal year ended December 31, 2023. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. These forward-looking statements speak only as of the date made, and other than as required by law, we undertake no obligation to update or revise any forward-looking statement or provide reasons why actual results may differ, whether as a result of new information, future events or otherwise.

Introduction

The following discussion and analysis presents management’s view of our business, financial condition and overall performance and should be read in conjunction with our Consolidated Financial Statements and the accompanying notes. This information is intended to provide investors with an understanding of our past performance, current financial condition and outlook for the future.

Our discussion and analysis includes the following subjects:

•Overview

•Overview of Significant Events

•Results of Operations

•Liquidity and Capital Resources

•Summary of Critical Accounting Estimates

•Recent Accounting Standards

Overview

Cheniere, a Delaware corporation, is a Houston-based energy infrastructure company primarily engaged in LNG-related businesses. We provide clean, secure and affordable LNG to integrated energy companies, utilities and energy trading companies around the world. We aspire to conduct our business in a safe and responsible manner, delivering a reliable, competitive and integrated source of LNG to our customers.

LNG is natural gas (methane) in liquid form. The LNG we produce is shipped all over the world, converted back into natural gas (called “regasification”) and then transported via pipeline to homes and businesses and used as an energy source that is essential for heating, cooking, other industrial uses and back up for intermittent energy sources. Natural gas is a cleaner-burning, abundant and affordable source of energy. When LNG is converted back to natural gas, it can be used instead of coal, which reduces the amount of pollution traditionally produced from burning fossil fuels, like sulfur dioxide and particulate matter that enters the air we breathe. Additionally, compared to coal, it produces significantly fewer carbon emissions. By liquefying natural gas, we are able to reduce its volume by 600 times so that we can load it onto special LNG carriers designed to keep the LNG cold and in liquid form for efficient transport overseas.

We are the largest producer of LNG in the United States and we are the second largest LNG operator globally, based on the total production capacity of our liquefaction facilities, which totaled approximately 45 mtpa as of June 30, 2024.

We own and operate a natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG Terminal”), one of the largest LNG production facilities in the world, through our ownership interest in and management agreements with CQP, which is a publicly traded limited partnership that we formed in 2007. As of June 30, 2024, we owned 100% of the general partner interest, a 48.6% limited partner interest and 100% of the incentive distribution rights of CQP. The Sabine Pass LNG Terminal has six operational Trains, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG Terminal also has operational regasification facilities that include five LNG storage tanks with aggregate capacity of approximately 17 Bcfe and vaporizers with regasification capacity of approximately 4 Bcf/d, as well as three marine berths, two of which can accommodate vessels with nominal capacity of up to 266,000 cubic meters and the third berth which can accommodate vessels with nominal capacity of

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up to 200,000 cubic meters. We also own and operate a 94-mile natural gas supply pipeline that interconnects the Sabine Pass LNG Terminal with several large interstate and intrastate pipelines (the “Creole Trail Pipeline”).

Additionally, we own and operate a natural gas liquefaction and export facility located near Corpus Christi, Texas (the “Corpus Christi LNG Terminal”) through CCL, which currently has natural gas liquefaction facilities consisting of three operational Trains for a total production capacity of approximately 15 mtpa of LNG, three LNG storage tanks with aggregate capacity of approximately 10 Bcfe and two marine berths that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters. We are constructing an expansion of the Corpus Christi LNG Terminal (the “Corpus Christi Stage 3 Project”) consisting of seven midscale Trains with an expected total production capacity of over 10 mtpa of LNG. We also own and operate a 21.5-mile natural gas supply pipeline that interconnects the Corpus Christi LNG Terminal with several large interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the existing assets at the Corpus Christi LNG Terminal and the Corpus Christi Stage 3 Project, the “CCL Project”).

Our long-term customer arrangements form the foundation of our business and provide us with significant, stable, long-term cash flows. We have contracted substantially all of our anticipated production capacity under SPAs, in which our customers are generally required to pay a fixed fee with respect to the contracted volumes irrespective of their election to cancel or suspend deliveries of LNG cargoes, and under IPM agreements, in which a gas producer sells natural gas to us on a global LNG or natural gas index price, less a fixed liquefaction fee, shipping and other costs. The SPAs also have a variable fee component, which is generally structured to cover the cost of natural gas purchases, transportation and liquefaction fuel consumed to produce LNG. Since we procure most of our feedstock for LNG production from the U.S., the structure of these contracts helps limit our exposure to fluctuations in U.S. natural gas prices. Through our SPAs and IPM agreements, we have contracted approximately 95% of the total anticipated production from the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) through the mid-2030s with approximately 16 years of weighted average remaining life as of June 30, 2024, excluding volumes from contracts with terms less than 10 years and volumes that are contractually subject to additional liquefaction capacity beyond what is currently in construction or operation. We also market and sell LNG produced by the Liquefaction Projects that is not contracted by CCL or SPL through our integrated marketing function.

We remain focused on safety, operational excellence and customer satisfaction. Increasing demand for LNG has allowed us to expand our liquefaction infrastructure in a financially disciplined manner. We have increased available liquefaction capacity at our Liquefaction Projects as a result of debottlenecking and other optimization projects. We believe these factors provide a foundation for additional growth in our portfolio of customer contracts in the future. We hold significant land positions at both the Sabine Pass LNG Terminal and the Corpus Christi LNG Terminal, which provide opportunity for further liquefaction capacity expansion. In March 2023, certain of our subsidiaries submitted an application with the FERC under the Natural Gas Act (the “NGA”) for an expansion adjacent to the CCL Project consisting of two midscale Trains with an expected total production capacity of approximately 3 mtpa of LNG (the “CCL Midscale Trains 8 & 9 Project”). Additionally, we are developing an expansion adjacent to the SPL Project with a total production capacity of up to approximately 20 mtpa of LNG, inclusive of estimated debottlenecking opportunities (the “SPL Expansion Project”). In February 2024, certain subsidiaries of CQP submitted an application to the FERC under the NGA for authorization to site, construct and operate the SPL Expansion Project, as well as an application to the DOE requesting authorization to export LNG to FTA countries and non-FTA countries, both of which applications exclude debottlenecking. The development of the CCL Midscale Trains 8 & 9 Project, the SPL Expansion Project or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a positive FID.

Additionally, we are committed to the management of our most important ESG impacts, risks and opportunities. In August 2023, we published The Power of Connection, our fourth Corporate Responsibility (“CR”) report, which details our approach and progress on ESG matters. Our CR report is available at cheniere.com/our-responsibility/reporting-center. Information on our website, including the CR report, is not incorporated by reference into this Quarterly Report on Form 10-Q.

Overview of Significant Events

Our significant events since January 1, 2024 and through the filing date of this Form 10-Q include the following:

Strategic

•In July 2024, Cheniere Marketing entered into a long-term SPA with Galp Trading S.A. (“Galp”), a subsidiary of Galp Energia, SGPS, S.A., under which Galp has agreed to purchase approximately 0.5 mtpa of LNG from Cheniere

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Marketing on a free-on-board basis. Deliveries are expected to commence in the early 2030s and are subject to, among other things, a positive Final Investment Decision with respect to the second train of the SPL Expansion Project.

•In June 2024, we received a positive Environmental Assessment from the FERC relating to the CCL Midscale Trains 8 & 9 Project. We expect to receive all remaining necessary regulatory approvals for the project in 2025.

•In February 2024, certain subsidiaries of CQP submitted an application to the FERC under the NGA for authorization to site, construct and operate the SPL Expansion Project, as well as an application to the DOE requesting authorization to export LNG to FTA countries and non-FTA countries, both of which applications exclude debottlenecking.

Operational

•As of August 2, 2024, approximately 3,570 cumulative LNG cargoes totaling over 245 million tonnes of LNG have been produced, loaded and exported from the Liquefaction Projects.

Financial

•In June 2024, we announced updates to our ‘20/20 Vision’ comprehensive long-term capital allocation plan, which included an increase to our share repurchase authorization by $4 billion through 2027 and, subject to declaration by our Board of Directors, an increase to our quarterly dividend by approximately 15% to $2.00 per common share annualized, commencing with the third quarter of 2024.

•In May 2024, CQP issued $1.2 billion aggregate principal amount of 5.750% Senior Notes due 2034 (the “2034 CQP Senior Notes”). In June 2024, the net proceeds, together with cash on hand, were used to retire $1.2 billion outstanding aggregate principal amount of SPL’s 5.625% Senior Secured Notes due 2025 (the “2025 SPL Senior Notes”).

•In May 2024, in connection with the 2034 CQP Senior Notes issuance, Moody’s Ratings (“Moody’s”) upgraded CQP’s issuer credit rating to Baa2 from Ba1 and revised CQP’s outlook to stable from positive. Moody’s also upgraded SPL’s issuer credit rating to Baa1 from Baa2 and revised SPL’s outlook to stable from positive. In July 2024, Fitch Ratings upgraded CCH’s issuer credit rating to BBB+ from BBB with a stable outlook.

•In March 2024, Cheniere issued $1.5 billion aggregate principal amount of 5.650% Senior Notes due 2034 (the “2034 Cheniere Senior Notes”). The net proceeds from the 2034 Cheniere Senior Notes, together with cash on hand, were used in April 2024 to retire the approximately $1.5 billion outstanding aggregate principal amount of CCH’s 5.875% Senior Secured Notes due 2025 (the “2025 CCH Senior Notes”).

•During the three and six months ended June 30, 2024, we accomplished the following pursuant to our capital allocation priorities:

◦We repurchased over 3.1 million and approximately 10.7 million shares of our common stock, respectively, as part of our share repurchase program for approximately $496 million and $1.7 billion, respectively.

◦SPL repaid $150 million and $300 million, respectively, of outstanding aggregate principal amount of its 5.750% Senior Secured Notes due 2024.

◦We paid dividends of $0.435 and $0.870 per share, respectively, of common stock.

◦We continued to invest in accretive organic growth, including our investment in the Corpus Christi Stage 3 Project, as further described under Investing Cash Flows in Sources and Uses of Cash within Liquidity and Capital Resources.

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Results of Operations

Consolidated results of operations


	Three Months Ended June 30,						Six Months Ended June 30,
(in millions, except per share data)	2024		2023		Variance		2024		2023		Variance
Revenues
LNG revenues	$	3,042	$	3,919	$	(877)	$	7,079	$	11,010	$	(3,931)
Regasification revenues	34		33		1		68		67		1
Other revenues	175		150		25		357		335		22

Total revenues	3,251		4,102		(851)		7,504		11,412		(3,908)

Operating costs and expenses (recoveries)
Cost (recovery) of sales (excluding items shown separately below)	784		912		(128)		3,020		(627)		3,647

Operating and maintenance expense	463		487		(24)		914		931		(17)
Selling, general and administrative expense	99		87		12		200		194		6
Depreciation and amortization expense	304		297		7		606		594		12



Other operating costs and expenses	13		11		2		22		21		1

Total operating costs and expenses	1,663		1,794		(131)		4,762		1,113		3,649

Income from operations	1,588		2,308		(720)		2,742		10,299		(7,557)

Other income (expense)
Interest expense, net of capitalized interest	(257)		(291)		34		(523)		(588)		65
Gain (loss) on modification or extinguishment of debt	(9)		(2)		(7)		(9)		18		(27)

Interest and dividend income	47		55		(8)		108		89		19
Other income, net	3		—		3		2		3		(1)
Total other expense	(216)		(238)		22		(422)		(478)		56

Income before income taxes and non-controlling interest	1,372		2,070		(698)		2,320		9,821		(7,501)
Less: income tax provision	210		363		(153)		319		1,679		(1,360)
Net income	1,162		1,707		(545)		2,001		8,142		(6,141)
Less: net income attributable to non-controlling interest	282		338		(56)		619		1,339		(720)
Net income attributable to Cheniere	$	880	$	1,369	$	(489)	$	1,382	$	6,803	$	(5,421)

Net income per share attributable to common stockholders—basic	$	3.85	$	5.65	$	(1.80)	$	5.97	$	27.99	$	(22.02)
Net income per share attributable to common stockholders—diluted	$	3.84	$	5.61	$	(1.77)	$	5.96	$	27.79	$	(21.83)

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Volumes loaded and recognized from the Liquefaction Projects



	Three Months Ended June 30,			Six Months Ended June 30,
(in TBtu)	2024	2023	Variance	2024	2023	Variance
Volumes loaded during the current period	552	534	18	1,153	1,136	17
Volumes loaded during the prior period but recognized during the current period	30	39	(9)	37	56	(19)
Less: volumes loaded during the current period and in transit at the end of the period	(30)	(26)	(4)	(30)	(26)	(4)
Total volumes recognized in the current period	552	547	5	1,160	1,166	(6)

Components of LNG revenues and corresponding LNG volumes delivered


	Three Months Ended June 30,						Six Months Ended June 30,
	2024		2023		Variance		2024		2023		Variance
LNG revenues (in millions):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	$	2,755	$	2,752	$	3	$	5,798	$	6,492	$	(694)
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	229		1,037		(808)		1,022		4,281		(3,259)
LNG procured from third parties	—		132		(132)		119		132		(13)

Net derivative gain (loss)	5		(53)		58		35		1		34
Other revenues	53		51		2		105		104		1
Total LNG revenues	$	3,042	$	3,919	$	(877)	$	7,079	$	11,010	$	(3,931)

Volumes delivered as LNG revenues (in TBtu):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	524		495		29		1,062		1,006		56
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	28		52		(24)		98		160		(62)
LNG procured from third parties	—		14		(14)		11		14		(3)
Total volumes delivered as LNG revenues	552		561		(9)		1,171		1,180		(9)

(1)Long-term agreements include agreements with an initial tenor of 12 months or more.

Net income attributable to Cheniere

Net income attributable to Cheniere declined $489 million and $5.4 billion for the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023. There was a $630 million and $2.6 billion decrease in LNG revenues, net of cost of sales and excluding the effect of derivatives, for the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023, the majority of which was attributable to declining international LNG and gas prices and a reduction of volumes sold under short-term agreements as a higher proportion of our LNG was sold under long-term contracts, as further described in Revenues below. The decline between the six month periods was primarily attributable to unfavorable changes in fair value and settlements of derivatives of $5.0 billion (before tax and the impact of non-controlling interest), principally attributable to our IPM agreements, where the associated gains decreased from $4.6 billion during the six months ended June 30, 2023 to $582 million during the six months ended June 30, 2024, mainly due to the impact on fair value of moderating changes in volatility in international gas prices in the current period relative to the same period of 2023. These unfavorable variances were partially offset by:

•$153 million and $1.4 billion favorable variances in income tax provision between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023, primarily due to lower taxable earnings; and

•$56 million and $720 million reduction in net income attributable to non-controlling interest between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023, substantially all of which is due to a decrease in CQP’s consolidated net income between the comparable periods from decreased revenues, net

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of cost of sales, between the three month periods and from declining gains from changes in fair value and settlements of derivatives between the six month periods.

The following is an additional discussion of the significant drivers of the variance in net income attributable to common stockholders by line item:

Revenues

The decreases of $851 million and $3.9 billion between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023 were primarily attributable to:

•$940 million and $3.3 billion decreases in revenues generated by our marketing function under short-term agreements between the three and six month periods, respectively, due to declining international LNG and gas prices and a reduction of volumes sold under short-term agreements as a result of additional long-term agreements commencing after the second quarter of 2023; and

•$694 million decrease in revenues attributable to declining Henry Hub pricing between the six month periods, to which the majority of our long-term LNG sales contracts are indexed. Although there was a decrease in revenue from Henry Hub pricing between the three month periods, it was mostly offset by the increase in volume from the higher proportion of our volumes sold under long-term agreements.

Operating costs and expenses (recoveries)

There was a $131 million favorable variance between the three months ended June 30, 2024 and 2023 primarily as a result of a $307 million decrease in cost of natural gas feedstock largely due to lower U.S. natural gas prices, partially offset by a $176 million unfavorable variance from changes in fair value and settlements of derivatives included in cost of sales.

There was a $3.6 billion unfavorable variance between the six months ended June 30, 2024 and 2023 primarily attributable to a $5.1 billion unfavorable variance from changes in fair value and settlements of derivatives included in cost of sales. $4.0 billion of such unfavorable variance resulted from the moderating volatility in international gas prices during the current period, resulting in decreased non-cash gain in fair value of our IPM agreements indexed to such prices during the six month periods, as described above under the caption Net income attributable to Cheniere, and the remainder of the variance resulted from decreased gains from changes in fair value and settlements of the derivatives associated with other term supply natural gas and power supply contracts. This unfavorable variance was partially offset by a $1.4 billion decrease between the periods in cost of sales excluding the effect of derivative changes described above, primarily as a result of a $1.3 billion decrease in cost of natural gas feedstock largely due to lower U.S. natural gas prices.

Other income (expense)

The $22 million and $56 million favorable variances between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023 were primarily attributable to:

•$34 million and $65 million decreases in interest expense, net of capitalized interest, between the three and six month periods, respectively, primarily due to increases in the extent of interest costs qualifying for capitalization, given the higher carrying value of assets under construction, and additionally due to lower overall interest cost due to debt reduction activities associated with our long-term capital allocation plan.

•$7 million and $27 million increases in loss on modification or extinguishment of debt between the three and six month periods, respectively, from debt reduction activities, as further detailed under Financing Cash Flows in Sources and Uses of Cash within Liquidity and Capital Resources.

•$8 million decrease in interest and dividend income between the three month periods as a result of lower average cash and cash equivalents balances between the respective periods, partially offset by higher interest rates in 2024, and a $19 million increase in interest and dividend income between the six month periods as a result of higher interest income earned on cash and cash equivalents from higher interest rates in 2024.

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Income tax provision

The $153 million and $1.4 billion favorable variances between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023, were primarily attributable to decreases in pre-tax income.

Our effective tax rate was 15.3% and 13.8% for the three and six months ended June 30, 2024, respectively, as compared to 17.5% and 17.1% for the same periods of 2023, respectively. The effective tax rate for the periods was lower than the statutory rate of 21.0% primarily due to CQP’s income that is not taxable to us. Our effective tax rate decreased between both comparable periods because a larger percentage of pre-tax income was attributable to CQP’s income that is not taxable to us.

Net income attributable to non-controlling interests

The $56 million and $720 million decreases between the three and six months ended June 30, 2024, respectively, as compared to the same periods of 2023 were attributable to a $52 million decrease in CQP’s consolidated net income between the three month periods primarily from decreased revenues, net of cost of sales, and a $1.3 billion decrease in CQP’s consolidated net income between the six month periods primarily from unfavorable changes in fair value and settlements of derivatives, of which $1.0 billion was related to the IPM agreement with Tourmaline Oil Marketing Corp.

Significant factor affecting our results of operations

Below is a significant factor that affects our results of operations.

Gains and losses on derivative instruments

Derivative instruments, which in addition to managing exposure to commodity-related marketing and price risks are utilized to manage exposure to changing interest rates and foreign exchange volatility, are reported at fair value on our Consolidated Financial Statements. For commodity derivative instruments related to our IPM agreements, the underlying LNG sales being economically hedged are accounted for under the accrual method of accounting, whereby revenues expected to be derived from the future LNG sales are recognized only upon delivery or realization of the underlying transaction. Notwithstanding the operational intent to mitigate risk exposure over time, the recognition of derivative instruments at fair value has the effect of recognizing gains or losses relating to future period exposure, and given the significant volumes, long-term duration and volatility in price basis for certain of our derivative contracts, the use of derivative instruments may result in continued volatility of our results of operations based on changes in market pricing, counterparty credit risk and other relevant factors that may be outside of our control. For example, as described in Note 5 —Derivative Instruments of our Notes to Consolidated Financial Statements, the fair value of the Liquefaction Supply Derivatives incorporates, as applicable, market participant-based assumptions pertaining to certain contractual uncertainties, including those related to the availability of market information for delivery points, which may require future development of infrastructure, as well as the timing of satisfaction of certain events or development of infrastructure to support natural gas gathering and transport. We may recognize changes in fair value through earnings that could significantly impact our results of operations if and when such uncertainties are resolved.

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Liquidity and Capital Resources

The following information describes our ability to generate and obtain adequate amounts of cash to meet our requirements in the short term and the long term. In the short term, we expect to meet our cash requirements using operating cash flows and available liquidity, consisting of cash and cash equivalents, restricted cash and cash equivalents and available commitments under our credit facilities. Additionally, we expect to meet our long term cash requirements by using operating cash flows and other future potential sources of liquidity, which may include debt and equity offerings by us or our subsidiaries. The table below provides a summary of our available liquidity (in millions). Future material sources of liquidity are discussed below.


	June 30, 2024
Cash and cash equivalents (1)	$	2,442







Restricted cash and cash equivalents (1)	512
Available commitments under our credit facilities (2):

SPL Revolving Credit Facility	762
CQP Revolving Credit Facility	1,000

CCH Credit Facility	3,260
CCH Working Capital Facility	1,390
Cheniere Revolving Credit Facility	1,250

Total available commitments under our credit facilities	7,662

Total available liquidity	$	10,616

(1)Amounts presented include balances held by our consolidated variable interest entities (“VIEs”), as discussed in Note 6 —Non-controlling Interests and Variable Interest Entities of our Notes to Consolidated Financial Statements. As of June 30, 2024, assets of our VIEs, which are included in our Consolidated Balance Sheets, included $351 million of cash and cash equivalents and $79 million of restricted cash and cash equivalents.

(2)Available commitments represent total commitments less loans outstanding and letters of credit issued under each of our credit facilities as of June 30, 2024. See Note 8 —Debt of our Notes to Consolidated Financial Statements for additional information on our credit facilities and other debt instruments.

Our liquidity position subsequent to June 30, 2024 will be driven by future sources of liquidity and future cash requirements. For a discussion of our future sources and uses of liquidity, see the liquidity and capital resources disclosures in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

Although our sources and uses of cash are presented below from a consolidated standpoint, SPL, CQP, CCH and Cheniere operate with independent capital structures. Certain restrictions or requirements under debt and equity instruments executed by our subsidiaries limit the entity’s use of cash, including the following:

•SPL and CCH are required to deposit all cash received into restricted cash and cash equivalents accounts under certain of their debt agreements. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Projects and other restricted payments. In addition, SPL and CCH’s operating costs are managed by our subsidiaries under affiliate agreements, which may require SPL and CCH to advance cash to the respective affiliates, however the cash remains restricted for operation and construction of the Liquefaction Projects;

•CQP is required under its partnership agreement to distribute to unitholders all available cash on hand at the end of a quarter less the amount of any reserves established by its general partner. Beginning with the distribution paid in the second quarter of 2022, quarterly distributions by CQP are currently comprised of a base amount plus a variable amount equal to the remaining available cash per unit, which takes into consideration, among other things, amounts reserved for annual debt repayment and capital allocation goals, anticipated capital expenditures to be funded with cash, and cash reserves to provide for the proper conduct of CQP’s business;

•Our 48.6% limited partner interest, 100% general partner interest and incentive distribution rights in CQP limit our right to receive cash held by CQP to the amounts specified by the provisions of CQP’s partnership agreement; and

•SPL and CCH are restricted by affirmative and negative covenants included in certain of their debt agreements in their ability to make certain payments, including distributions, unless specific requirements are satisfied.

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Despite the restrictions noted above, we believe that sufficient flexibility exists within the Cheniere complex to enable each independent capital structure to meet its currently anticipated cash requirements. The sources of liquidity at SPL, CQP and CCH primarily fund the cash requirements of the respective entity, and any remaining liquidity not subject to restriction, as supplemented by liquidity provided by Cheniere Marketing, is available to enable Cheniere to meet its cash requirements.

Corpus Christi Stage 3 Project

The following table summarizes the project completion and construction status of the Corpus Christi Stage 3 Project as of June 30, 2024:



Overall project completion percentage						62.4%
Completion percentage of:
Engineering						93.7%
Procurement						80.3%
Subcontract work						83.9%
Construction						24.4%
Date of expected substantial completion						1H 2025 - 2H 2026

Sources and Uses of Cash

The following table summarizes the sources and uses of our cash, cash equivalents and restricted cash and cash equivalents (in millions). The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, which are referred to elsewhere in this report. Additional discussion of these items follows the table.


	Six Months Ended June 30,
	2024		2023

Net cash provided by operating activities	$	2,362	$	5,000
Net cash used in investing activities	(1,185)		(1,068)
Net cash used in financing activities	(2,746)		(1,253)
Effect of exchange rate changes on cash, cash equivalents and restricted cash and cash equivalents	(2)		3

















Net increase (decrease) in cash, cash equivalents and restricted cash and cash equivalents	$	(1,571)	$	2,682

Operating Cash Flows

The $2.6 billion decrease between the periods was primarily related to lower cash receipts from the sale of LNG cargoes due to a reduction in both pricing per MMBtu and volumes sold under short-term agreements, although this exposed us less to declining international LNG and gas prices in the current year as a higher proportion of our LNG was sold under long-term agreements. The decrease was partially offset by lower cash outflows for natural gas feedstock, mostly due to lower U.S. natural gas prices.

We became subject to the 15% CAMT beginning in 2024. Accordingly, our U.S. federal income tax obligations are expected to accelerate relative to prior periods, subject to and conditioned on variability in our pre-tax GAAP income, including period-to-period volatility attributable to changes in the fair value of our derivative instruments. As any accelerated CAMT tax liability provides an offsetting credit against our regular U.S. federal income tax liability for future years, we expect that any future impact will be limited to timing differences. Please refer to our annual report on Form 10-K for the fiscal year ended December 31, 2023 for additional discussion of the potential impacts of CAMT on our future liquidity.

Investing Cash Flows

Our investing net cash outflows in both periods primarily were for the construction costs for the Corpus Christi Stage 3 Project, which were $909 million during the six months ended June 30, 2024 compared to $729 million in the comparable period of 2023. We expect to incur a similar level of capital expenditures in the second half of the year as construction work progresses on the Corpus Christi Stage 3 Project.

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Financing Cash Flows

The following table summarizes our financing activities (in millions):


	Six Months Ended June 30,
	2024		2023
Proceeds from issuances of debt	$	2,725	$	1,397
Redemptions, repayments and repurchases of debt	(3,021)		(1,098)


Distributions to non-controlling interest	(451)		(513)
Payments related to tax withholdings for share-based compensation	(41)		(56)
Repurchase of common stock	(1,699)		(774)
Dividends to stockholders	(202)		(195)
Other, net	(57)		(14)
Net cash used in financing activities	$	(2,746)	$	(1,253)

Debt Issuances

The following table shows our debt issuances (in millions):


	Six Months Ended June 30,
	2024		2023
Proceeds from issuances of debt
Cheniere:
2034 Cheniere Senior Notes	$	1,497	$	—

CQP:
2034 CQP Senior Notes	1,198		—
5.950% Senior Notes due 2033	—		1,397

SPL:
SPL Revolving Credit Facility	30		—
Total proceeds from issuances of debt	$	2,725	$	1,397

Debt Redemptions, Repayments and Repurchases

The following table shows the redemptions, repayments and repurchases of debt, including intra-quarter repayments (in millions):


	Six Months Ended June 30,
	2024		2023
Redemptions, repayments and repurchases of debt
SPL:
5.750% Senior Secured Notes due 2024	$	(300)	$	(200)
5.625% Senior Secured Notes due 2025	(1,200)		—

SPL Revolving Capital Facility	(30)		—






CCH:


7.000% Senior Notes due 2024	—		(498)
5.625% Senior Notes due 2025	(1,491)		—
5.125% Senior Notes due 2027	—		(69)
3.700% Senior Notes due 2029	—		(237)
2.742% Senior Notes due 2039	—		(94)









Total redemptions, repayments and repurchases of debt	$	(3,021)	$	(1,098)

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Repurchase of Common Stock

During the six months ended June 30, 2024 and 2023, we paid $1.7 billion and $774 million to repurchase 10.7 million and 5.4 million shares of our common stock, respectively, under our share repurchase program. As of June 30, 2024, we had approximately $4.5 billion remaining under our share repurchase program.

Cash Dividends to Stockholders

During the six months ended June 30, 2024, we paid aggregate dividends of $0.870 per share of common stock, for a total of $202 million. We paid aggregate dividends of $0.790 per share of common stock for a total of $195 million during the six months ended June 30, 2023.

On June 17, 2024, we declared a quarterly dividend of $0.435 per share of common stock that is payable on August 16, 2024 to stockholders of record as of the close of business on August 9, 2024.

Summary of Critical Accounting Estimates

The preparation of Consolidated Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

Recent Accounting Standards

For a summary of recently issued accounting standards, see Note 1—Nature of Operations and Basis of Presentation of our Notes to Consolidated Financial Statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Marketing and Trading Commodity Price Risk

We have derivatives consisting of natural gas supply contracts for the commissioning and operation of the SPL Project and the CCL Project, and associated economic hedges (collectively, the “Liquefaction Supply Derivatives”). We have also entered into physical and financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”). In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives and the LNG Trading Derivatives to changes in underlying commodity prices, management modeled a 10% change in the commodity price for natural gas for each delivery location and a 10% change in the commodity price for LNG, respectively, as follows (in millions):


	June 30, 2024				December 31, 2023
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
Liquefaction Supply Derivatives	$	(1,753)	$	1,466	$	(2,117)	$	1,526
LNG Trading Derivatives	(17)		14		10		12

See Note 5 —Derivative Instruments of our Notes to Consolidated Financial Statements for additional details about our commodity derivative instruments.

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ITEM 4. CONTROLS AND PROCEDURES

We maintain a set of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports filed by us under the Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that our disclosure controls and procedures are effective.

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. There have been no material changes to the legal proceedings disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

ITEM 1A. RISK FACTORS

There have been no material changes from the risk factors disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2023.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Purchase of Equity Securities by the Issuer and Affiliated Purchasers

The following table summarizes share repurchases for the three months ended June 30, 2024:


Period	Total Number of Shares Purchased	Average Price Paid Per Share (1)	Total Number of Shares Purchased as a Part of Publicly Announced Plans	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans (in millions) (2)
April 1-30, 2024	1,298,558	$158.18	1,298,558	$744
May 1-31, 2024	1,295,875	$157.75	1,295,875	$540
June 1-30, 2024	547,066	$158.15	547,066	$4,453
Total	3,141,499		3,141,499

(1)The price paid per share was based on the average trading price of our common stock on the dates on which we repurchased the shares.

(2)On June 14, 2024, our Board authorized an increase in the existing repurchase program by $4.0 billion, effective through December 31, 2027.

ITEM 5. OTHER INFORMATION

Rule 10b5-1 under the Exchange Act provides an affirmative defense that enables prearranged transactions in securities in a manner that avoids concerns about initiating transactions at a future date while possibly in possession of material nonpublic information. Our Insider Trading Policy permits our directors and executive officers to enter into trading plans designed to comply with Rule 10b5-1. During the three-month period ending June 30, 2024, none of our executive officers or directors adopted or terminated a Rule 10b5-1 trading plan or adopted or terminated a non-Rule 10b5-1 trading arrangement (as defined in Item 408(c) of Regulation S-K).

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ITEM 6. EXHIBITS

Exhibit No.

Description

4.1

Ninth Supplemental Indenture, dated as of May 22, 2 024, among CQP, the guarantors party thereto and The Bank of New York Mellon, as Trustee under the Indenture (incorporated by reference to Exhibit 4.1 to the CQP 's Current Report on Form 8-K (SEC File No. 001-33366 ), filed on Ma y 22 , 2024)

10.1*

Change orders to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Corpus Christi Liquefaction Stage 3 Project, dated March 1, 2022, by and between CCL and Bechtel Energy, Inc.: (i) the Change Order CO-00086 CCL Tanks “A” and “C” Engineering, Procurement and Construction, dated March 15, 2024, (ii) the Change Order CO-00087 HAZOP Package #6 (“Phase Four Items”), dated January 1, 2024, (iii) the Change Order CO-00088 FERC & PHMSA (DOT) Support Hours (Through to Period 24-Dec-2023), dated February 2, 2024, and (iv) the Change Order CO-00089 30PK-3301A/B/C Firewater Pump Protection - Blast Analysis, Design and Calculation Report, dated May 7, 2024 (Portions of this exhibit have been omitted.)

10.2

Registration Rights Agreement, dated as of May 22 , 2024, among CQP, the guarantor party thereto, BofA Securities, Inc., Citigroup Global Markets Inc., ING Financial Markets LLC, MUFG Securities Americas Inc ., SMBC Nikko Securities America, Inc. and Standard C hartered Bank (incorporated by reference to Exhibit 10.1 to CQP 's Current Report on Form 8-K (SEC File No. 001-33366 ), filed on Ma y 22 , 2024)

10.3

Cheniere Energy, Inc. Amended and Restated 2020 Incentive Plan (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383 ), filed on May 24, 2024)

10.4*

First Amendment to Second A&R Term Loan Facility Agreement, dated April 19, 2024

10.5*

First Amendment to Second A&R Common Terms Agreement, dated April 19, 2024

10.6*

First Amendment to Second A&R Common Security and Account Agreement, dated April 19, 2024

10.7*

First Amendment to Second A&R Working Capital Facility Agreement, dated April 19, 2024

31.1*

Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

31.2*

Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act

32.1**

Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2**

Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.INS*

XBRL Instance Document

101.SCH*

XBRL Taxonomy Extension Schema Document

101.CAL*

XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*

XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*

XBRL Taxonomy Extension Labels Linkbase Document

101.PRE*

XBRL Taxonomy Extension Presentation Linkbase Document

104*

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)


*			Filed herewith.
**			Furnished herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


		CHENIERE ENERGY, INC.







Date:	August 7, 2024	By:	/s/ Zach Davis
			Zach Davis
			Executive Vice President and Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)

Date:	August 7, 2024	By:	/s/ David Slack
			David Slack
			Senior Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)